FIELD
[0001] The present disclosure relates to production of hydrocarbon material from a subterranean
formation and controlling entrainment of solids within the produced hydrocarbon material.
BACKGROUND
[0002] Production of hydrocarbon reservoirs is complicated by the presence of solid particulate
matter that is entrained within the produced fluid. Such solid particulate matter
includes naturally-occurring solids debris, such as sand. It also includes solids,
such as proppant, which have been intentionally injected into the reservoir, in conjunction
with treatment fluid, for improving the rate of hydrocarbon production from the reservoir.
The entrained solids can complicate operations by causing erosion and interfering
with fluid flow.
[0003] US 2014/345876 discloses a selectively openable inflow control sub. The sub includes a tubular body
and an inflow port that extends through a wall of the body. The sub further includes
a sliding sleeve valve that is slidable within an inner bore of the tubular body between
a closed-port position, closing the inflow port, and an open-port position, opening
the inflow port to fluid flow therethrough. The sliding sleeve valve is axially moveable
from the closed-port position and the open-port position by pushing the sleeve with
a mill string.
[0004] US 2013/168099 discloses an apparatus for fluid treatment of a borehole. The apparatus effects initial
outflow injection of fluids into a wellbore in which it is installed, and then is
actuable to allow fluid inflow control. The apparatus includes a tubular body, a first
port and a second port opened through the wall of the tubular body, wherein the second
port has a fluid inflow controller positioned to control the flow of fluid into the
tubular body through the port. The apparatus further includes a sliding sleeve valve
in the tubular body that is moveable from (i) a first position, wherein the first
and second ports are closed by the sleeve valve, to (ii) a second position, wherein
the second port is closed by the sleeve valve, while fluid flow through the first
port is permitted by the sleeve valve, to (iii) a third position, wherein the first
port is closed by the sleeve valve, while fluid flow through the second port is permitted
by the sleeve valve. The apparatus further includes a sleeve actuator for actuating
the sliding sleeve valve to move from the first position to the second position in
response to a force applied thereto. The apparatus further includes a releasable lock
for locking the sliding sleeve valve in the first position and selected to maintain
the sliding sleeve valve in the first position after the force is removed, and a lock
release mechanism configured to actuate the releasable lock to release the sliding
sleeve valve to move into the third position.
[0005] US 2014/224471 discloses an apparatus for fluid treatment of a borehole. The apparatus includes
a tubular body, a first port extending through the wall of the tubular body, and a
second port extending through the wall of the tubular body. The second port has a
fluid inflow control mechanism positioned to control the flow of fluid into the tubular
body through the port. The first port is configurable from an open position to a closed
position. The apparatus further includes a controller to actuate the first port into
the closed position, a set time after the first port is placed into the open position.
SUMMARY
[0006] There is provided a hydrocarbon production process, implemented via a system including
a wellbore string disposed within a wellbore extending into a subterranean formation,
wherein the wellbore string includes a flow communication station including a material
injection station and a material production station, wherein the material production
station is disposed downhole relative to the material injection station, wherein the
material injection station includes a material injection flow control member for opening
and closing a material injection flow communicator that is disposed in flow communication
with the subterranean formation via a wellbore space, and the material production
station includes a material production flow control member for opening and closing
a material production flow communicator that is disposed in flow communication with
the subterranean formation via a wellbore space, wherein the material production flow
communicator includes a filter medium for preventing oversize particulate material
from entering the wellbore string, comprising:
opening the material injection flow communicator by displacing the material injection
flow control member, relative to the material injection flow communicator, from the
closed position to the open position with a shifting tool;
while: (i) the material injection flow communicator is disposed in the open condition,
and (ii) a sealed interface is disposed within the wellbore string, downhole relative
to the material injection flow communicator, and uphole relative to the material production
flow communicator, with effect that bypassing of the material injection flow communicator,
by stimulation material injected from the surface, is prevented or substantially prevented,
injecting stimulation material, including proppant, from the surface and into the
subterranean formation, via the wellbore string, the material injection flow communicator,
and the wellbore space, such that hydraulic fracturing of a hydrocarbon material-containing
reservoir of the subterranean formation is effected;
continuing to inject the stimulation material with effect that a screen out is obtained,
with effect that the frac pack is obtained within the wellbore space, between the
subterranean formation and the material production flow communicator; and
after the frac pack has been obtained:
opening the material production flow communicator by displacing the material production
flow control member, relative to the material production flow communicator, from the
closed position to the open position, with a shifting tool; and
after the opening of the material production flow communicator, producing hydrocarbon
material from the subterranean formation via the frac pack, the material production
station and the wellbore string.
[0007] In another aspect, there is provided a hydrocarbon production process, implemented
via a system including a wellbore string disposed within a wellbore extending into
a subterranean formation, wherein the wellbore string includes a material injection
station and a material production station, wherein the material production station
is disposed downhole relative to the material injection station, wherein the material
injection station includes a material injection flow controller for modulating a flow
communication condition of a material injection flow communicator that is disposed
in flow communication with the subterranean formation via a wellbore space, and the
material production station includes a material production flow controller for modulating
a flow communication condition of a material production flow communicator that is
disposed in flow communication with the subterranean formation via a wellbore space,
wherein the material production flow communicator includes a filter medium for preventing
oversize particulate material from entering the wellbore string, comprising:
opening the material injection flow communicator by displacing the material injection
flow controller relative to the material injection flow communicator;
while the material injection flow communicator is disposed in the open condition,
injecting stimulation material, including proppant entrained within a fluid, from
the surface and into the subterranean formation, via the wellbore string, the material
injection flow communicator, and the wellbore space, such that hydraulic fracturing
of a hydrocarbon material-containing reservoir of the subterranean formation is effected;
suspending the injection of the stimulation material;
after the suspending of the injection of the stimulation material, partially opening
the material production flow communicator by displacing the material production flow
controller relative to the material production flow communicator, such that:
- (i) an uphole-disposed portion of the material production flow communicator is occluded
by the material production flow controller; and
- (ii) flow communication is effected between the subterranean formation and the wellbore
string via a downhole-disposed portion of the material production flow communicator,
such that reservoir material is conducted from the subterranean formation and into
the wellbore string via the downhole-disposed portion of the material production flow
communicator in response to a pressure differential between the subterranean formation
and the wellbore string, and such that solid particulate material, entrained within
the conducted reservoir material, separates from the conducted reservoir material
and accumulates within the wellbore space, that is disposed between the subterranean
formation and the material production flow communicator, and at least contributes
to formation of a solid particulate material-containing filtering medium;
wherein the downhole-disposed portion of the material production flow communicator
is disposed downhole relative to the uphole-disposed portion of the material production
flow communicator;
and
after the formation of a solid particulate material-containing filtering medium, increasing
the percentage opening of the material production flow communicator by displacing
the material production flow controller relative to the material production flow communicator
such that a production mode material production flow communicator is established,
with effect that reservoir material is conducted from the subterranean formation and
into the wellbore string via the solid particulate material-containing filtering medium
and the production mode material production flow communicator.
BRIEF DESCRIPTION OF DRAWINGS
[0008] The preferred embodiments will now be described with the following accompanying drawings,
in which:
Figure 1 is a schematic illustration of a system of the present disclosure;
Figure 1A is a schematic illustration of an embodiment of an apparatus of the material
injection station of the system illustrated in Figure 1, showing the flow control
member disposed in the closed position;
Figure 1B is a schematic illustration of the apparatus of the material injection station
illustrated in Figure 1A, showing the flow control member disposed in the open position;
Figure 2 is a sectional view of an embodiment of an apparatus of the material production
station of the system illustrated in Figure 1, showing the flow control member disposed
in the closed position;
Figure 2A is a detailed view of Detail A in Figure 2;
Figure 2B is a detailed view of Detail B in Figure 2
Figure 2C is a detailed view of Detail C in Figure 2;
Figure 3 is a sectional view of the apparatus illustrated in Figure 2, showing the
flow control member disposed in the intermediate position;
Figure 3A is a detailed view of Detail A in Figure 3;
Figure 3B is a detailed view of Detail B in Figure 3;
Figure 3C is a detailed view of Detail C in Figure 3;
Figure 4 is a sectional view of the apparatus illustrated in Figure 2, showing the
flow control member disposed in the open position;
Figure 4A is a detailed view of Detail A in Figure 4;
Figure 4B is a detailed view of Detail B in Figure 4;
Figure 4C is a detailed view of Detail C in Figure 4;
Figure 5 is a schematic illustration of a partially completed embodiment of the screened
port of the apparatus illustrated in Figure 2, showing screen having been wrapped
around a portion of a perforated base pipe;
Figure 6 is a schematic illustration of an exemplary flow communication station of
a system of the present disclosure;
Figure 7 is a schematic illustration of the system illustrated in Figure 6, showing
injection of stimulation material into subterranean formation via the material injection
station for formation of a frac pack;
Figure 8 is a schematic illustration of an exemplary flow communication station of
the system illustrated in Figure 6, after a frac pack has been obtained, and while
a clean out is on-going;
Figure 9 is a schematic illustration of the system illustrated in Figure 6 during
production;
Figure 10 is a schematic illustration of another exemplary flow communication station
of a system of the present disclosure;
Figure 11 is a schematic illustration of the system illustrated in Figure 10, showing
injection of stimulation material into subterranean formation, via the material injection
station, for effecting hydraulic fracturing of the subterranean formation;
Figure 12 is a schematic illustration of the system in Figure 10, after the injection
of stimulation material has been suspended and the material production flow communicator
has been partially opened; and
Figure 13 is a schematic illustration of the system in Figure 10, after the the material
production flow communicator has been fully opened.
DETAILED DESCRIPTION
[0009] Referring to Figure 1, there is provided a system 2 for producing hydrocarbon material
from a subterranean formation 100 including a plurality of flow communication stations
(in the illiustrated embodiment, five, 200A-E, are illustrated) disposed within a
wellbore 102. Successive flow communication stations 200A-E are spaced from each other
within the wellbore 102, along a longitudinal axis of the wellbore 102, such that
each one of the flow communication stations 200A-E, independently, is positioned adjacent
a zone of the subterranean formation for effecting flow communication between the
wellbore 102 and the zone. In this respect, each one of the flow communication stations
200A-E, independently, is configured for effecting flow communication between the
surface and a respective zone within the subterranean formation 100.
[0010] The wellbore 102 can be straight, curved, or branched. The wellbore 102 can have
various wellbore sections. A wellbore section is an axial length of a wellbore 102.
A wellbore section can be characterized as "vertical" or "horizontal" even though
the actual axial orientation can vary from true vertical or true horizontal, and even
though the axial path can tend to "corkscrew" or otherwise vary. The term "horizontal",
when used to describe a wellbore section, refers to a horizontal or highly deviated
wellbore section as understood in the art, such as, for example, a wellbore section
having a longitudinal axis that is between 70 and 110 degrees from vertical.
[0011] In some embodiments, for example, for each one of the flow communication stations
200A-E, the flow communication, between the flow communication station and the respective
zone of the subterranean formation, is effected by integrating the flow communication
station 200, in succession, into a production string 202 that is disposed within the
wellbore 102. In some of these embodiments, for example, the disposition of the production
string 202 within the wellbore 102 is such that a wellbore space 104, such as an annular
space, is established within the wellbore 102, between the production string 202 and
the subterranean formation 100.
[0012] The wellbore space includes a plurality of wellbore space sections 104A-E. Each one
of the wellbore space sections 104A-E, independently, is respective to a one of the
flow communication stations 200A-E, such that, for each one of the flow communication
stations 200A-E, flow communication, between the flow communication station and the
subterranean formation, is effected via a respective one of the wellbore space sections
104A-E.
[0013] Each one of the flow communication stations 200A-E, independently, includes a material
injection station 204 and a material production station 206.
[0014] For each one of the flow communication stations 200A-E, independently, the material
injection station 204 includes an apparatus 2042. Referring to Figures 1A and 1B,
the apparatus 2042 includes a housing 2044. The housing 2044 includes a passage 2046.
A material injection flow communicator 2048 extends through the housing 2044. In some
embodiments, for example, the material injection flow communicator 2048 includes one
or more ports. The material injection flow communicator 2048 is configured for effecting
flow communication between the housing passage 2046 and the subterranean formation.
[0015] The apparatus 2042 further includes a material injection flow controller 2050 configured
for controlling flow communication between the housing passage 2046 and the material
injection flow communicator 2048. In some embodiments, for example, the material injection
flow controller 250 is a flow control member 250. In some embodiments, for example,
the material injection flow controller 250 is in the form of a sleeve that is slidable,
relative to the flow communicator 2048, within the housing passage 2046. In some embodiments,
for example, the flow control member 2050 is configured for opening and closing the
material injection flow communicator 2048.
[0016] In some embodiments, for example, while the flow control member 2050 is disposed
in the closed position (see Figure 1A), the material injection flow communicator 2048
is disposed in a closed condition. In some embodiments, for example, in the closed
condition, the flow communicator 2048 is occluded by the flow control member 2050.
In some embodiments, for example, while the flow communicator 2048 is disposed in
the closed condition, there is an absence, or substantial absence of fluid communication
between the passage 2046 and the subterranean formation 100 via the material production
flow communicator 2048. In other words, fluid communication between the passage 2046
and the subterranean formation 100 via the flow communicator 2048 is prevented or
substantially prevented. In some embodiments, for example, while the flow control
member 2050 is disposed in the closed position, a sealed interface is established,
preventing, or substantially preventing, flow communication, via the material injection
flow communicator 2048, between the surface 4 and the subterranean formation 100.
In some embodiments, for example, the closed position of the material injection flow
control member 2050 is established by abutting engagement of the flow control member
2050 with the hard stop 2060 that is disposed uphole of the material injection flow
communicator 2048.
[0017] In some embodiments, for example, while the flow control member 2050 is disposed
in the open position (see Figure 1B), flow communication, between the surface and
the respective zone of the subterranean formation 100, is effected via the material
injection flow communicator 2048. In some embodiments, for example, while the flow
control member 250 is disposed in the open position, the flow communicator 2048 is
disposed in an open condition. In some embodiments, for example, while the flow communicator
is disposed in the open condition, there is an absence of occlusion of any portion,
or substantially any portion, of the flow communicator 2048 by the flow control member
250. In some embodiments, for example, the disposition of the flow control member
250 in the open position is such that the entirety, or substantially the entirety,
of the flow communicator 2048 is non-occluded by the flow control member 250. In some
embodiments, for example, the open position of the material injection flow control
member 2050 is established by abutting engagement of the flow control member 2050
with the hard stop 2062 that is disposed downhole of the material injection flow communicator
2048.
[0018] In some embodiments, for example, while the flow control member 250 is disposed in
the closed position, the flow control member 250 is releasably retained relative to
the housing 2044. Similarly, in some embodiments, for example, while the flow control
member 250 is disposed in the open position, the flow control member 250 is releasably
retained relative to the housing 2044. The releasable retention of the flow control
member 250, relative to the housing 2044, can be effected by a collet retainer 2070,
similar to the manner by which the flow control member 14, of the material production
station 206, is releasably retained by a collet retainer 22, as described below.
[0019] While the material injection flow communicator 2048 is disposed in the open condition,
treatment material is injectable from the surface and into the subterranean formation
via the flow communicator 2048 for stimulating production of a hydrocarbon material-containing
reservoir within the subterranean formation.
[0020] In some embodiments, for example, the treatment material includes a liquid, such
as a liquid including water. In some embodiments, for example, the liquid includes
water and chemical additives. In other embodiments, for example, the stimulation material
is a slurry including water and solid particulate matter, such as proppant. In some
embodiments, for example the treatment material includes chemical additives. Exemplary
chemical additives include acids, sodium chloride, polyacrylamide, ethylene glycol,
borate salts, sodium and potassium carbonates, glutaraldehyde, guar gum and other
water soluble gels, citric acid, and isopropanol. In some embodiments, for example,
the treatment material is injected into the subterranean formation for effecting hydraulic
fracturing of the reservoir.
[0021] In some embodiments, for example, while the apparatus 10 is being deployed downhole,
the flow control member 250 is maintained in the closed position, by one or more frangible
interlocking members 2501 (such as, for example, shear pins), such that the material
injection flow communicator 2048 remains disposed in the closed condition while the
deployment is occurring. The one or more frangible interlocking members are provided
to releasably secure the flow control member 250 to the housing 2044 so that the passage
2046 is maintained fluidically isolated from the subterranean formation 100 until
it is desired to effect hydrocarbon production from the subterranean formation 100.
[0022] For each one of the flow communication stations 200A-E, independently, the material
production station 206 includes an apparatus 10. Referring to Figures 2 to 5, the
apparatus 10 includes a housing 12. The housing 12 includes a passage 16. A material
production flow communicator 15 extends through the housing 12. In some embodiments,
for example, the material production flow communicator 15 includes one or more ports.
The material injection flow communicator 15 is configured for effecting flow communication
between the housing passage 16 and the subterranean formation, such as for effecting
the receiving of hydrocarbon material, from the subterranean formation, by the production
string 202. The material production flow communicator 15 includes a filter medium
15AA configured for preventing, or substantially preventing, oversize solid particulate
matter from being conducted from the subterranean formation 100 and into the production
string 202. In some embodiments, for example, the filter medium is in the form of
a screen, such as a wire screen. In some embodiments, for example, the filter medium
15AA is defined by a sand screen that is wrapped around a perforated section (defined
by ports 15CC) of a base pipe 15BB, the perforated section defining a plurality of
apertures. In some embodiments, for example, the filter medium is in the form of a
porous material that is integrated within an aperture of a base pipe. In some embodiments,
for example, the filter medium is configured for preventing, or substantially preventing,
passage of + 100 mesh proppant from the subterranean formation 100, via the material
production flow communicator 15, and into the production string 202.
[0023] The apparatus 10 further includes a material production flow controller 14 configured
for controlling flow communication between the housing passage 16 and the material
production flow communicator 15. In some embodiments, for example, the material production
flow controller 14 is a flow control member 14. In some embodiments, for example,
the flow control member 14 is in the form of a sleeve that is slidable, relative to
the flow communicator 15, within the housing passage 16. In some embodiments, for
example, the flow control member 14 is configured for opening and closing the material
injection flow communicator 15.
[0024] For each one of the flow communication stations 200A-E, the integration of the flow
communication station into the production string 202 is with effect that the material
production station 206 is disposed downhole relative to the material injection station
204.
[0025] Referring to Figures 2, 2A, 2B, and 2C, while the flow control member 14 is disposed
in the closed position, the material production flow communicator is disposed in the
closed condition. In some embodiments, for example, in the closed condition, the entirety,
or the substantial entirety, of the material production flow communicator 15 is occluded
by the flow control member 14. In some embodiments, for example, while the flow communicator
15 is disposed in a closed condition, there is an absence, or substantial absence
of fluid communication between the passage 16 and the subterranean formation 100 via
the material production flow communicator 15. In other words, fluid communication
between the passage 16 and the subterranean formation 100 via the material production
flow communicator 15 is prevented or substantially prevented. In some embodiments,
for example, while the flow control member 14 is disposed in the closed position,
a sealed interface is established, preventing, or substantially preventing, flow communication,
via the material production flow communicator 15, between the surface 4 and the subterranean
formation 100.
[0026] Referring to Figures 4, 4A, 4B, and 4C, while the flow control member 14 is disposed
in the open position, flow communication, between the surface and the respective zone
of the subterranean formation 100, is effected via the material production flow communicator
15. In some embodiments, for example, while the flow control member is disposed in
the open position, the material production flow communicator 15 is disposed in an
open condition. In some embodiments, for example, while the material production flow
communicator 15 is disposed in the open condition, there is an absence of occlusion
of any portion, or substantially any portion, of the material production flow communicator
15 by the flow control member 14; In some embodiments, for example, the disposition
of the flow control member 14 in the open position is such that the entirety, or substantially
the entirety, of the material production flow communicator 15 is non-occluded by the
flow control member 14.
[0027] In some embodiments, for example, the flow control member 14 is displaceable from
the closed position to the open position for effecting flow communication between
the subterranean formation 100 and the passage 16 such that reservoir fluids are producible
via the wellbore 102.
[0028] In some embodiments, for example, the flow control member 14 is displaceable from
the open position to the closed position while fluids are being produced from the
subterranean formation 100 through the material production flow communicator 15, and
in response to sensing of a sufficiently high rate of water production from the subterranean
formation 100 through the material production flow communicator 15. In such case,
moving the flow control member 14 blocks further production through the material production
flow communicator 15.
[0029] In some embodiments, for example, the flow control member 14 is displaceable along
an axis that is parallel to the central longitudinal axis of the passage 16.
[0030] In some embodiments, for example, the housing 12 includes sealing surfaces 11A, 11B
configured for sealing engagement with the flow control member 14 for effecting the
sealed interface coincident with the flow communicator 15 being disposed in the closed
condition. In this respect, in some embodiments, for example, the flow control member
14 includes sealing members 11AA, 11BB. The material production flow communicator
15 is disposed between the sealing surfaces 11A, 11B. In some embodiments, for example,
when the flow control member 14 is disposed in a position corresponding to the closed
position of the flow communicator 15, each one of the sealing members 11AA, 11BB,
is, independently, disposed in sealing engagement with both of the housing 12 and
the flow control member 14.
[0031] In some embodiments, for example, each one of the sealing members 11AA, 11BB, independently,
includes an o-ring. In some embodiments, for example, the o-ring is housed within
a recess formed within the flow control member 14. In some embodiments, for example,
each one of the sealing members 11AA, 11BB, independently, includes a molded sealing
member (i.e. a sealing member that is fitted within, and/or bonded to, a groove formed
within the sub that receives the sealing member).
[0032] In some embodiments, for example, the flow control member 14 cooperates with the
sealing surfaces 11A, 11B to effect opening and closing of the material production
flow communicator 15. While the material production flow communicator 15 is disposed
in the closed position, the flow control member 14 is sealingly engaged to both of
the sealing surfaces 11A, 11B. While the material production flow communicator 15
is disposed in the open condition, the flow control member 14 is spaced apart or retracted
from at least one of the sealing surfaces (referring to Figure 4, in the illustrated
embodiment, this would be the sealing surface 11B), thereby providing a passage for
reservoir material to be conducted to the passage 16 via the material production flow
communicator 15.
[0033] In some embodiments, while disposed in the closed position, the flow control member
14 is releasable retained relative to the housing 12. In this respect, in some embodiments,
for example, a retaining collet 22 extends from the housing 12, and is configured
to engage the flow control member 14 for resisting a displacement of the flow control
member. In some embodiments, for example, the retaining collet 22 includes at least
one resilient flow control member-engaging collet finger 22A, and each one of the
at least one flow control member-engaging collet finger includes a tab 22B that engages
the flow control member. The flow control member 14 and the retaining collet 22 are
co-operatively configured such that engagement of the flow control member 14 by the
flow control member-engaging collet 22 is effected while the material production flow
communicator 15 is disposed in the closed condition.
[0034] Referring to Figure 2, 2A, 2B, and 2C, while the flow control member 14 is disposed
in the closed position (i.e. the material production flow communicator 15 is disposed
in the closed condition) the retaining collet 22 is engaging the flow control member
14 such that interference or resistance is being effected to displacement of the flow
control member 14, such that the flow control member 14 is releasably retained relative
to the housing 12. The flow control member 14 includes a closed condition-defining
recess 24. The at least one flow control member-engaging collet finger 22A and the
recess 24 are co-operatively configured such that, while the flow control member-engaging
collet finger tab 22B is disposed within the closed condition-defining recess 24,
the flow control member 14 is disposed in the closed position. In order to effect
a displacement of the flow control member 14, while the flow control member-engaging
collet finger tab 22B is disposed within the closed condition-defining recess 24,
a first displacement force is applied to the flow control member 14 to effect displacement
of the tab 22B from (or out of) the recess 24. Such displacement is enabled due to
the resiliency of the collet finger 22A. Once the flow control member-engaging collet
finger tab 22B has become displaced out of the recess 24, continued application of
force to the flow control member 14 (such as, in the embodiments illustrated in Figures
2, 2A, 2B, and 2C, in a downhole direction) effects displacement of the flow control
member 14, relative to the material production flow communicator 15.
[0035] Similarly, in some embodiments, for example, while disposed in the open position,
the flow control member 14 is releasably retained relative to the housing 12, such
as, for example, by the retaining collet 22. In this respect, and referring to Figures
4, 4A, 4B, and 4C, while the flow control member 14 is disposed in the open position
(i.e. the material production flow communicator 15 is disposed in the open condition),
the retaining collet 22 is engaging the flow control member 14 such that interference
or resistance is being effected to displacement of the flow control member 14, such
that the flow control member 14 is releasably retained relative to the housing 12.
The flow control member 14 includes an open condition-defining recess 26. The at least
one flow control member-engaging collet finger 22A and the recess 26 are co-operatively
configured such that, while the flow control member-engaging collet finger tab 22B
is disposed within the open condition-defining recess 26, the flow communicator 15
is disposed in the open condition. In order to effect a displacement of the flow control
member 14, while the flow control member-engaging collet finger tab 22B is disposed
within the open condition-defining recess 26, a second displacement force is applied
to the flow control member 14 to effect displacement of the tab from (or out of) the
recess 26. Such displacement is enabled due to the resiliency of the collet finger
22A. Once the flow control member-engaging collet finger tab 22B has become displaced
out of the recess 26, continued application of the second displacement force to the
flow control member 14 (such as, in the embodiment illustrated in Figure 2, in a downhole
direction) effects displacement of the flow control member 14, relative to the material
production flow communicator 15.
[0036] Referring to Figure 2, in some embodiments, for example, while the apparatus 10 is
being deployed downhole, the flow control member 14 is maintained in the closed position,
by one or more frangible interlocking members 30 (such as, for example, shear pins),
such that the material production flow communicator 15 remains disposed in the closed
condition while the deployment is occurring. The one or more frangible interlocking
members 30 are provided to releasably retain the flow control member 14 to the housing
12 so that the passage 16 is maintained fluidically isolated from the subterranean
formation 100 until it is desired to effect hydrocarbon production from the subterranean
formation 100. In some embodiments, for example, the one or more frangible interlocking
members 30 extends through apertures 14B provided in a centralizer portion 14A of
the flow control member 14.
[0037] While the flow control member 14 is releasably retained to the housing by the one
or more frangible interlocking members 30, the flow control member 14 is disposed
in a retained position. To effect the fracturing of the frangible interlocking members
30 such that the flow control member 14 is displaceable relative to the material production
flow communicator 15, sufficient force must be applied to the flow control member
14 such that the one or more frangible interlocking members 30 become fractured, resulting
in the flow control member 14 becoming displaceable relative to the material production
flow communicator 15.
[0038] In some embodiments, for example, while the flow control member 14 is retained relative
to the housing 12 by the one or more frangible interlocking members 30, the flow control
member 14 is positioned downhole relative to the space occupied by the flow control
member 14 while disposed in the open position. In such embodiments, for example, the
one or more frangible interlocking members 30 are configured for fracturing (such
that the flow control member 14 is displaceable relative to the material production
flow communicator 15) by application of a sufficient downhole force. Upon the fracturing
of the one or more frangible interlocking members 30, continued application of the
downhole force effects displacement of the flow control member 14 in a downhole direction.
If the downhole force were permitted to continue to effect the displacement of the
flow control member 14 in a downhole direction (such as, for example to effect opening
of the material production flow communicator 15), the flow control member 14 would
continue to accelerate, and attain a sufficiently high speed, such that, upon rapid
deceleration of the flow control member 14 caused by an obstruction to its downhole
displacement (such as by a hard stop), associated components become vulnerable to
damage. In this respect, the displacement of the flow control member 14, relative
to the flow communicator 15, in a downhole direction, that is effected after the fracturing
of the one or more frangible interlocking members 30, is limited by a hard stop 32
that extends from the housing 12 and into the passage 16. The flow control member
14 and the hard stop 32 are co-operatively configured such that, while the flow control
member 14 is disposed in abutting engagement with the hard stop 32 (i.e. the flow
control member 14 is disposed in the downhole displacement-limited position), displacement
of the flow control member 14 relative to the flow communicator 15, in the downhole
direction, is prevented or substantially prevented by the hard stop 32. The flow control
member, 14, while disposed in the releasably retained position by the one or more
frangible interlocking members 30, and the hard stop 32 are co-operatively disposed
such that the distance by which the flow control member 14 is displaced by the applied
force, after its release from retention relative to the housing 12 by the one or more
frangible interlocking members 30, is sufficiently short such that the speed attained
by the flow control member 14, during the displacement of the flow control member
14 relative to the flow communicator 15, is sufficiently slow such that there is an
absence of undesirable mechanical damage to associated components upon impact (i.e
the abutting engagement) of the hard stop 32 by the flow control member 14 (see Figures
3, 3A, 3B, and 3C). In this respect, In some embodiments, for example, the distance
by which the flow control member 14 is displaced, relative to the flow communicator
15, between the retained position and the downhole-displacement limited position,
as measured along the central longitudinal axis of the passage 16, is less than six
(6) inches, such as less than three (3) inches, such as less than two (2) inches.
[0039] Relatedly, in those embodiments where the material production flow communicator 15
has a dimension, measured along an axis that is parallel to the central longitudinal
axis of the passage 16, that is greater than the distance by which the flow control
member 14 is displaced, relative to the flow communicator 15, from the secured position
and the downhole displacement-limited position, as measured along the central longitudinal
axis of the passage, in order to effect opening of the flow communicator 15 such that
the flow communicator becomes disposed in the non-occluded condition (i.e. there is
an absence, or substantial absence, of occlusion of any portion of the flow communicator
15 by the flow control member 14), the displacement of the flow control member 14,
relative to the flow communicator 15, from the retained position to the open position,
is a displacement in the uphole direction. Otherwise, if such displacement of the
flow control member 14, relative to the flow communicator 15, for effecting opening
of the flow communicator 15 such that the flow communicator 15 becomes disposed in
the non-occluded condition, were a displacement in the downhole direction, the hard
stop 32 would need to, correspondingly, be positioned further downhole so as to permit
sufficient downhole displacement of the flow control member 14 to effect the opening
of the material production flow communicator 15. In such case, as a consequence, the
speed attainable by the flow control member 14, while the downhole force continues
to be applied (after the fracturing of the one or more frangible interlocking members
30) for effecting such displacement, is sufficiently high such that associated components
are vulnerable to damage upon the flow control member 14 impacting (i.e. becoming
disposed in abutting engagement with) the hard stop 32. Similar concerns about component
damage are not present while displacing the flow control member 14, relative to the
flow communicator 15, in an uphole direction, after having initially fractured the
one or more frangible interlocking members 30 with an applied force in the downhole
direction. This is because it is easier to maintain a lower applied force (such as,
for example, a pulling up force applied to the workstring to which the shifting tool
is coupled) to effect such uphole displacement, relative to the material production
flow communicator 15, in these circumstances, relative to the above-described circumstances
where the displacement of the flow control member 14, to effect opening of the material
production flow communicator 15, is effected by a force that continues to be applied
after having effected the fracturing of the one or more frangible interlocking members
30.
[0040] In some embodiments, for example, a dimension of the material production flow communicator
15, measured along an axis that is parallel, or substantially parallel, to the central
longitudinal axis of the passage 16, is at least one (1) foot, such as, for example,
at least three (3) feet, such as, for example, at least five (5) feet, or such as,
for example, at least eight (8) feet. In some embodiments, for example, a dimension
of the material production flow communicator 15, measured along an axis that is parallel
to the central longitudinal axis of the passage 16, is ten (10) feet. Relatedly, the
minimum distance, by which the flow control member 14 is displaced (in the uphole
direction), relative to the flow communicator 15, along an axis that is parallel,
or substantially parallel, to the central longitudinal axis of the passage 16, from
the retained position, wherein the displacement is with effect that the flow communicator
15 becomes disposed in the non-occluded condition, is at least one (1) foot, such
as, for example, at least three (3) feet, such as, for example, at least five (5)
feet, or such as, for example, at least eight (8) feet, and, in some embodiments,
for example, is ten (10) feet. Also relatedly, the minimum distance, by which the
flow control member 14 is displaced (in the uphole direction), relative to the flow
communicator 15, along an axis that is parallel, or substantially parallel, to the
central longitudinal axis of the passage 16, from the retained position, wherein the
displacement is with effect that the entirety, or the substantial entirety, of the
flow communicator 15 is non-occluded by the flow control member 14, is at least one
(1) foot, such as, for example, at least three (3) feet, such as, for example, at
least five (5) feet, or such as, for example, at least eight (8) feet, and, in some
embodiments, for example, is ten (10) feet. Also relatedly, the distance, by which
the flow control member 14 is displaced (in the uphole direction), relative to the
flow communicator 15, along an axis that is parallel, or substantially parallel, to
the central longitudinal axis of the passage 16, from the closed position, wherein
the displacement is with effect that the flow communicator 15 becomes disposed in
the non-occluded condition, is at least one (1) foot, such as, for example, at least
three (3) feet, such as, for example, at least five (5) feet, or such as, for example,
at least eight (8) feet, and, in some embodiments, for example, is ten (10) feet.
Also relatedly, the distance, by which the flow control member 14 is displaced (in
the uphole direction), relative to the flow communicator 15, along an axis that is
parallel, or substantially parallel, to the central longitudinal axis of the passage
16, from the closed position, wherein the displacement is with effect that the entirety,
or the substantial entirety, of the flow communicator 15 is non-occluded by the flow
control member 14, is at least one (1) foot, such as, for example, at least three
(3) feet, such as, for example, at least five (5) feet, or such as, for example, at
least eight (8) feet, and, in some embodiments, for example, is ten (10) feet. Also
relatedly, the distance, by which the flow control member 14 is displaced (in the
uphole direction), relative to the flow communicator 15, along an axis that is parallel,
or substantially parallel, to the central longitudinal axis of the passage 16, from
the position at which the flow control member 14 is disposed while in abutting engagement
with the hard stop 32, wherein the displacement is with effect that the flow communicator
15 becomes disposed in the non-occluded condition, is at least 14 inches, such as,
for example, at least 38 inches, such as, for example, at least 62 inches, or such
as, for example, at least 98 inches, and, in some embodiments, for example, is 122
inches. Also relatedly, the distance, by which the flow control member 14 is displaced
(in the uphole direction), relative to the flow communicator 15, along an axis that
is parallel, or substantially parallel, to the central longitudinal axis of the passage
16, from the position at which the flow control member 14 is disposed while in abutting
engagement with the hard stop 32, wherein the displacement is with effect that the
entirety, or the substantial entirety, of the flow communicator 15 is non-occluded
by the flow control member 14, is at least 14 inches, such as, for example, at least
three (3) feet, such as, for example, at least 62 inches, or such as, for example,
at least 98 inches, and, in some embodiments, for example, is 122 inches.
[0041] Referring to Figures 4, 4A, 4B, and 4C, in some embodiments, for example, the apparatus
10 includes a hard stop 34 for limiting displacement of the flow control member 14,
in an uphole direction, relative to the material production flow communicator 15.
In this respect, when disposed in abutting engagement with the hard stop 34, the flow
control member 14 is disposed in the open position. In this respect, the hard stop
34 determines the open position of the flow control member 14.
[0042] In some embodiments, for example, all of the displacement forces are imparted by
a shifting tool, and the shifting tool is integrated within a bottom hole assembly
208 that includes other functionalities. The bottomhole assembly may be deployed within
the wellbore on a workstring. Suitable workstrings include tubing string, wireline,
cable, or other suitable suspension or carriage systems. Suitable tubing strings include
jointed pipe, concentric tubing, or coiled tubing. The workstring includes a passage,
extending from the surface, and disposed in, or disposable to assume, fluid communication
with the fluid conducting structure of the tool. The workstring is coupled to the
bottomhole assembly such that forces applied to the workstring are translated to the
bottomhole assembly to actuate movement of the flow control member 14. All of the
displacement forces are impartable in such embodiments by a shifting tool that is
actuable by a workstring because, for amongst other reasons, each one of the first,
second, and third positions are determined by a respective hard stop, and which, therefore,
facilitates the positioning of the flow control member 14 such that positioning of
flow control member is not entirely dependent on the manipulation of the shifting
tool.
[0043] The flow communication stations 200A-E and the wellbore space sections 104A-E are
co-operatively configured such that, for each one of the flow communication stations
200A-E, independently,:
- (i) the flow communication station is disposed in flow communication with a respective
zone of the subterranean formation 100 via the respective wellbore space section,
and
- (ii) flow communication between the respective wellbore space section and the other
ones of the wellbore space sections 104A-E is sealed or substantially sealed such
that:
- (a) stimulation material, that is being injected from the material injection station
204 of a flow communication station and into the wellbore space section, is prevented,
or substantially prevented, from bypassing the respective zone of the subterranean
formation 100; and
- (b) hydrocarbon material, that is being received within the respective wellbore space
section from the respective zone of the subterranean formation 100, is prevented,
or substantially prevented, from bypassing the material production station 206.
[0044] In some embodiments, for example, the wellbore is a cased-hole completion.
[0045] In some embodiments, for example, the wellbore 102 includes a cased-hole completion.
A cased-hole completion involves running casing down into the wellbore 102 through
the production zone. The casing 106 at least contributes to the stabilization of the
subterranean formation 100 after the wellbore 102 has been completed, by at least
contributing to the prevention of the collapse of the subterranean formation 100 that
is defining the wellbore 102. In some embodiments, for example, the casing 106 includes
one or more successively deployed concentric casing strings, each one of which is
positioned within the wellbore 102, having one end extending from the well head 50.
In this respect, the casing strings are typically run back up to the surface. In some
embodiments, for example, each casing string includes a plurality of jointed segments
of pipe. The jointed segments of pipe typically have threaded connections.
[0046] The annular region between the deployed casing 106 and the subterranean formation
100 may be filled with zonal isolation material for effecting zonal isolation. The
zonal isolation material is disposed between the casing 106 and the subterranean formation
100 for the purpose of effecting isolation, or substantial isolation, of one or more
zones of the subterranean formation 100 from fluids disposed in another zone of the
subterranean formation 100. Such fluids include formation fluid being produced from
another zone of the subterranean formation 100 (in some embodiments, for example,
such formation fluid being flowed through a production string 202 disposed within
and extending through the casing 106 to the surface), or injected stimulation material.
In this respect, in some embodiments, for example, the zonal isolation material is
provided for effecting sealing, or substantial sealing, of flow communication between
one or more zones of the subterranean formation 100 and one or more others zones of
the subterranean formation 100 via space between the casing 106 and the subterranean
formation 100. By effecting the sealing, or substantial sealing, of such flow communication,
isolation, or substantial isolation, of one or more zones of the subterranean formation
100, from another subterranean zone (such as a producing formation) via the is achieved.
Such isolation or substantial isolation is desirable, for example, for mitigating
contamination of a water table within the subterranean formation 100 by the formation
fluids (e.g. oil, gas, salt water, or combinations thereof) being produced, or the
above-described injected fluids.
[0047] In some embodiments, for example, the zonal isolation material is disposed as a sheath
within an annular region between the casing 106 and the subterranean formation 100.
In some embodiments, for example, the zonal isolation material is bonded to both of
the casing 106 and the subterranean formation 100. In some embodiments, for example,
the zonal isolation material also provides one or more of the following functions:
(a) strengthens and reinforces the structural integrity of the wellbore, (b) prevents,
or substantially prevents, produced formation fluids of one zone from being diluted
by water from other zones. (c) mitigates corrosion of the casing 106, and (d) at least
contributes to the support of the casing 106. The zonal isolation material is introduced
to an annular region between the casing 106 and the subterranean formation 100 after
the subject casing 106 has been run into the wellbore 102. In some embodiments, for
example, the zonal isolation material includes cement.
[0048] In those embodiments where the wellbore is a cased-hole completion and the production
string 202 is spaced apart from the casing 106 such that the wellbore space is established,
the casing 106 is perforated for effecting flow communication between the flow communication
stations 200A-E and the subterranean formation 100. In this respect, a plurality of
perforations 110 extend from the wellbore space, through the casing 106, and into
the subterranean formation 100, and flow communication between the flow communication
stations 200A-E and the subterranean formation 100 is effected via the wellbore space
104 and the perforations 100.
[0049] In this respect, the flow communication stations 200A-E, the wellbore space sections
104A-E, and the perforations are co-operatively configured such that, for each one
of the flow communication stations 200A-E, independently,:
- (i) the flow communication station is disposed in flow communication with the respective
zone of the subterranean formation 100 via the respective wellbore space section and
a respective one or more perforations 100, and
- (ii) flow communication between the respective wellbore space section and the other
ones of the wellbore space sections 104A-E is sealed or substantially sealed such
that:
- (a) stimulation material, that is being injected from the material injection station
204 of a flow communication station and into the wellbore space section, is prevented,
or substantially prevented, from bypassing the respective zone of the subterranean
formation 100; and
- (b) hydrocarbon material, that is being received within the respective wellbore space
section from the respective zone of the subterranean formation 100, is prevented,
or substantially prevented, from bypassing the material production station 206.
[0050] In some embodiments, for example, the sealing, or substantial sealing, of the flow
communication is effected by disposing sealing members, such as packers 108A-F, between
adjacent ones of the wellbore space sections 104A-E.
[0051] In some embodiments, for example, for each one of the flow communication stations
200A-E, independently, the material production station 206 is disposed in alignment,
or substantial alignment, with the respective one or more perforations 110.
[0052] In one aspect, a hydrocarbon material production process is implemented via the system
100.
[0053] Referring to Figures 6 to 9, the process includes, for each one of the flow communication
stations 200A-E, in succession in the uphole direction from the furthest downhole-disposed
flow communication station, forming a frac pack between the one or more perforations
and the material production flow communicator 15. The frac pack, amongst other things,
mitigates production of fine particulate matter. The forming of a frac pack includes:
opening the material injection flow communicator 2048 by displacing the material injection
flow controller 2050, relative to the material injection flow communicator 2048, from
the closed position to the open position with a shifting tool;
while the material injection flow communicator 2048 is disposed in the open condition,
injecting stimulation material, including proppant, from the surface 4 and into the
subterranean formation 100, via the production string 202, the material injection
flow communicator 2048, the wellbore space, and the one or more perforations 110 (see
Figure 7), with effect that hydraulic fracturing of a hydrocarbon material-containing
reservoir within the subterranean formation 100;
continuing to inject the stimulation material with effect that a screen out is obtained,
with effect that the frac pack 212 is obtained within the wellbore space section,
between the one or more perforations and the material production flow communicator
(see Figure 7);
[0054] In some embodiments, for example, after the frac pack has been obtained, the stimulation
material that has accumulated within the production string 202 is cleaned out, such
as, for example, by circulating fluid within the wellbore between the surface and
the flow communication station (see Figure 8).
[0055] In some embodiments, for example, a sealed interface 210 is disposed within the production
string 202, downhole relative to the material injection flow communicator 2048. In
some embodiments, for example, the sealed interface 210 is provided for preventing,
or substantially preventing, bypassing of the material injection flow communicator
2048, by stimulation material injected from the surface 4.
[0056] In some embodiments, for example, the sealed interface 210 is disposed uphole relative
to the material production flow communicator 15. In this respect, in some of these
embodiments, for example, prior to the producing (see below), the sealed interface
210 is defeated.
[0057] In some embodiments, for example, the sealed interface 210 is established, at least
in part, with a packer, such as, for example, a packer that is deployed with a bottomhole
assembly.
[0058] In some embodiments, for example, for each one of the flow communication stations
200A-E, independently, the injection of the stimulation material is effected while
the material production flow communicator 15 is disposed in the closed condition.
[0059] In some embodiments, for example, after the frac pack has been obtained, and prior
to forming a frac pack for the next uphole one of the flow communication stations
200A-E, the material injection flow communicator 2048 is closed by displacement of
the material injection flow controller 2050 relative to the flow communicator 2048
with effect that the flow communicator 2048 becomes occluded by the flow controller
2050. In some embodiments, for example, such closing of the flow communicator 2048
enables the cleaning out of the injected stimulation material, as above-described.
[0060] After the frac pack 212 has been obtained for each one of the flow communication
stations 200A-E, as above-described, for each one of the flow communication stations
200A-E, independently, and in succession, and while: (i) the material injection flow
communicator 2048 is disposed in a closed condition, and (ii) the sealed interface
210 has been removed/defeated, the flow control member 14 is displaced for effecting
opening of the material production flow communicator 15, to thereby effect production,
via the production string 202, of hydrocarbon material from the subterranean formation
100 (see Figure 9). In such case, the hydrocarbon material, prior to entering the
production string 202, is conducted through the obtained frac pack, thereby effecting
removal of some solid particulate matter from the hydrocarbon material before its
entry into the production string 202.
[0061] Referring to Figures 10 to 13, in another aspect, another hydrocarbon material production
process is provided for implementation with the system 100. In this respect, the process
includes:
opening the material injection flow communicator 2048 by displacing the material injection
flow controller 2050 relative to the material injection flow communicator 2048;
while the material injection flow communicator 2048 is disposed in the open condition,
injecting stimulation material 300, including proppant entrained within a fluid, from
the surface and into the subterranean formation 100, via the wellbore string 202,
the material injection flow communicator 2048, and the wellbore space, such that hydraulic
fracturing of a hydrocarbon material-containing reservoir of the subterranean formation
100 is effected (see Figure 11);
suspending the injection of the stimulation material;
after the suspending of the injection of the stimulation material, partially opening
the material production flow communicator 15 by displacing the material production
flow controller 14 relative to the material production flow communicator 15, such
that:
- (i) an uphole-disposed portion 15A of the material production flow communicator is
occluded by the material production flow controller 14; and
- (ii) flow communication is effected between the subterranean formation 100 and the
wellbore string 202 via a downhole-disposed portion 15B of the material production
flow communicator 15, such that reservoir material is conducted from the subterranean
formation 100 and into the wellbore string 202 via the downhole-disposed portion 15B
of the material production flow communicator 15 in response to a pressure differential
between the subterranean formation 100 and the wellbore string 202, and such that
solid particulate material, entrained within the conducted reservoir material, separates
from the conducted reservoir material and accumulates within the wellbore space 200,
that is disposed between the subterranean formation and the material production flow
communicator, and at least contributes to formation of a solid particulate material-containing
filtering medium 120 (see Figure 12);
wherein the downhole-disposed portion 15B of the material production flow communicator
15 is disposed downhole relative to the uphole-disposed portion 15A of the material
production flow communicator 15;
and
after the formation of a solid particulate material-containing filtering medium 120,
increasing the percentage opening of the material production flow communicator 15
by displacing the material production flow controller 14 relative to the material
production flow communicator 15 such that a production mode material production flow
communicator 15C is established, with effect that reservoir material is conducted
from the subterranean formation to the wellbore string 202 via the solid particulate
material-containing filtering medium 120 and the production mode material production
flow communicator 15C (see Figure 13).
[0062] The reservoir material 400, including hydrocarbon material, that is received within
the wellbore string 202 is produced to the surface.
[0063] In some embodiments, for example, the partial opening of the flow communicator 15
is such that the fluid velocity and pressure differential between the reservoir and
the wellbore string 202 will transport material from the reservoir to the filter through
natural flowback. In some embodiments, for example, the flowback velocity is controlled
through open flow area of the material production flow communicator 15 so as to not
exceed the erosional fluid velocity limits on the flow communicator 15 while exceeding
the transport velocity required to deposit materials around the material production
flow communicator 15. Both cases are governed by the magnitude of reservoir pressure
present.
[0064] In some embodiments, for example, the solid particulate material-containing filtering
medium 120 includes solid particulate material that has accumulated during the injection
of stimulation material.
[0065] In some embodiments, for example, the partial opening of the material production
flow communicator 15 is with effect that the uphole-disposed portion 15A, of the material
production flow communicator 15 that is being occluded by the flow controller 14,
defines at least 50% of the total cross-sectional flow area of the material production
flow communicator 15, such as, for example, .at least 75% of the total cross-sectional
flow area of the material production flow communicator 15. In some embodiments, for
example, the increasing of the percentage opening of the material production flow
communicator 15 is with effect that the material production flow communicator 15 is
disposed in the non-occluded condition.
[0066] In some embodiments, for example, the injection of the stimulation material is effected
while the material production flow communicator 15 is disposed in the closed condition.
In some embodiments, for example, the injection of the stimulation material is effected
while a sealed interface 204 is disposed within the wellbore string 202, downhole
relative to the material injection flow communicator 2048.
[0067] In some embodiments, for example, where there is a sealed interface 204 disposed
uphole relative to the material production flow communicator 15, after the formation
of a solid particulate material-containing filtering medium 120, and prior to the
increasing of the percentage opening of the material production flow communicator
15, the sealed interface is defeated 204 (for example, a packer is unset).
[0068] In some embodiments, for example, prior to the partial opening of the material production
flow communicator 15, the material injection flow communicator 2048 is closed by displacing
the flow controller 2050 relative to the material injection flow communicator and
thereby occluding the material injection flow communicator 2048.
[0069] In some embodiments, for example, displacement of one, or both, of the flow control
members 250, 14, in the downhole direction, is effectible with a shifting tool, by
actuating a bottomhole assembly including a shifting tool and a suitable sealing member
(e.g. packer), such that the shifting tool becomes disposed in gripping engagement
with the second flow control member 216 and a suitable sealed interface is established,
and applying a fluid pressure differential across the sealed interface with effect
that the resulting force, being applied in a downhole direction, is translated by
the shifting tool to the flow control member 216. In those embodiments where the flow
control member is being maintained in the closed position, by one or more frangible
interlocking members, in some of these embodiments, for example, the translated force
is sufficient to effect fracturing of the frangible interlocking members, and thereby
effect release of the flow control member from the housing such that the flow control
member is displaceable relative to the flow communicator, such as by continued application
of the translated force. In those embodiments where the flow control member is releasably
retained relative to the housing (such as, for example, in the closed position) by
a collet retainer, the translated force is sufficient to effect displacement of the
collet retainer such that the flow control member becomes released relative to the
housing.
[0070] In some embodiments, for example, displacement of one, or both, of the flow control
members 250, 14, in the uphole direction, is effectible with a shifting tool, by actuating
a bottomhole assembly including a shifting tool, such that the shifting tool becomes
disposed in gripping engagement with the second flow control member 216 is established,
and applying a tensile force (a force applied in the uphole direction) to a workstring,
with effect that the applied tensile force (e..g. pulling up force) is translated
by the shifting tool to the flow control member 216. In those embodiments where the
flow control member is releasably retained relative to the housing (such as, for example,
in the open position) by a collet retainer, the translated force is sufficient to
effect displacement of the collet retainer such that the flow control member becomes
released relative to the housing.
[0071] In some embodiments, for example, the above-described displacements are effected
by the same shifting tool. In some embodiments, for example, an exemplary shifting
tool, for effecting the above-described displacements, is the SHIFT FRAC CLOSE
™ tool available from NCS Multistage Inc. In some embodiments, for example, the bottomhole
assembly 208 is any one of the embodiments of a bottomhole assembly described in
U.S. Patent Publication No. 2016/0251939 A1.
[0072] In the above description, for purposes of explanation, numerous details are set forth
in order to provide a thorough understanding of the present disclosure. However, it
will be apparent to one skilled in the art that these specific details are not required
in order to practice the present disclosure. Although certain dimensions and materials
are described for implementing the disclosed example embodiments, other suitable dimensions
and/or materials may be used within the scope of this disclosure. All such modifications
and variations, including all suitable current and future changes in technology, are
believed to be within the sphere and scope of the present disclosure.